Hydrocarbon production apparatus

ABSTRACT

An apparatus is disclosed for use in a hydrocarbon production well that includes a casing extending from a segment of the production well to a wellhead. A production conduit extends inside the casing, from a first end in the hydrocarbon production well to a second end at the wellhead. A receptacle includes a bottom spaced from the first end of the production conduit and at least one sidewall extending around a portion of the production conduit proximal the first end such that the receptacle extends around the first end of the production conduit. The receptacle includes an opening for liquid to pass into the receptacle to separate liquids from gases. A submersible pump is disposed in the production well and includes a motor outside the receptacle and coupled to a pump body inside the receptacle to pump the liquid from a pump inlet in the receptacle, through the production conduit to the second end.

INCORPORATION BY REFERENCE TO ANY PRIORITY APPLICATIONS

Any and all applications for which a foreign or domestic priority claimis identified in the Application Data Sheet as filed with the presentapplication are hereby incorporated by reference under 37 CFR 1.57.

This application claims priority to U.S. Provisional Application Ser.No. 61/891,301, filed Oct. 15, 2013, the disclosure of which isincorporated herein by reference in its entirety.

BACKGROUND

1. Field of the Invention

The present invention relates to the production of hydrocarbons such asheavy oils and bitumen from underground deposits by artificial liftingof the fluid including the hydrocarbons.

2. Description of the Related Art

When a hydrocarbon reservoir lacks sufficient energy for oil, gas, andwater to flow from wells at desired rates, supplemental productionmethods may be utilized. Gas and water injection for pressure support orsecondary recovery may be utilized to maintain well productivity. Whenfluids do not naturally flow to the surface or do not naturally flow ata sufficient rate, a pump or gas lift techniques may be utilized,referred to as artificial lift. Lift processes transfer energy downholeor decrease fluid density in wellbores to reduce the hydrostatic load onformations, and cause inflow. Commercial hydrocarbon volumes can beboosted or displaced to the surface. Artificial lift also improvesrecovery by reducing the bottomhole pressure at which wells becomeuneconomic and are abandoned. Also, the development of unconventionalresources such as viscous hydrocarbons usually include construction ofcomplex wells, and high hydrocarbon lifting rates are desirable toproduce oil quickly and efficiently at low cost.

Rod pump, gas lift, and electric submersible pumps are the most commonartificial lift systems. Hydraulic and progressing cavity pumps are alsoutilized. Electric submersible systems use multiple centrifugal pumpstages mounted in series within a housing, mated closely to asubmersible electric motor on the end of tubing and connected to surfacecontrols and electric power by an armor-protected cable. Submersiblesystems have a wide performance range. Standard surface electric drivespower outputs from 100 to 30,000 barrels per day and variable-speeddrives add pump-rate flexibility. High Gas Oil Ratio (GOR) fluids can behandled. Large gas volumes may lock up and destroy pumps, however.Submersible pumps may be operated at temperatures above 350° F. (177 C)utilizing special high-temperature motors and cables. High GOR, high-gasenvironments are now common in electric submersible pump applications.Reliable gas-handling technology is desirable to produce hydrocarbonsutilizing pumps.

Extensive deposits of viscous hydrocarbons exist around the world,including large deposits in the Northern Alberta oil sands, that are notsusceptible to standard oil well production technologies. One problemassociated with producing hydrocarbons from such deposits is that thehydrocarbons are too viscous to flow at commercially relevant rates atthe temperatures and pressures present in the reservoir. In some cases,such deposits are mined using open-pit mining techniques to extracthydrocarbon-bearing material for later processing to extract thehydrocarbons. Alternatively, thermal techniques may be used to heat thereservoir to mobilize the hydrocarbons and produce the heated, mobilizedhydrocarbons from wells. One such technique for utilizing a horizontalwell for injecting heated fluids and producing hydrocarbons is describedin U.S. Pat. No. 4,116,275, the content of which is incorporated hereinby reference in its entirety, which also describes some of the problemsassociated with the production of mobilized viscous hydrocarbons fromhorizontal wells.

One thermal method of recovering viscous hydrocarbons using spacedhorizontal wells is known as steam-assisted gravity drainage (“SAGD”).Various embodiments of the SAGD process are described in Canadian PatentNo. 1,304,287 and corresponding U.S. Pat. No. 4,344,485, the contents ofeach of which is incorporated herein by reference in its entirety. Inthe SAGD process, steam is pumped through an upper, horizontal,injection well into a viscous hydrocarbon reservoir while hydrocarbonsare produced from a lower, parallel, horizontal, production well that isvertically spaced and near the injection well. The injection andproduction wells are located close to the bottom of the hydrocarbondeposit to collect the hydrocarbons that flow toward the bottom.

The SAGD process is believed to work as follows. The injected steaminitially mobilizes the hydrocarbons to create a steam chamber in thereservoir around and above the horizontal injection well. The term steamchamber is utilized to refer to the volume of the reservoir that issaturated with injected steam and from which mobilized oil has at leastpartially drained. As the steam chamber expands upwardly and laterallyfrom the injection well, viscous hydrocarbons in the reservoir areheated and mobilized, in particular, at the margins of the steam chamberwhere the steam condenses and heats the viscous hydrocarbons by thermalconduction. The heated hydrocarbons and aqueous condensate drain, underthe effects of gravity, toward the bottom of the steam chamber, wherethe production well is located. The heated hydrocarbons and aqueouscondensate are collected and produced from the production well.

When the pressure in the steam chamber is sufficiently high, the fluidsproduced, including liquids and gases naturally flow through theproduction well, to the surface. The gases may include vapor, or waterin the form of steam, hydrocarbon gases, and other trace compounds. Theliquid may include hydrocarbons, water, and other compounds. Artificiallift may be utilized along with the SAGD process to increase the flowrate from the production well. Electric submersible pumps may beutilized in the production well to facilitate the flow of the fluids tothe surface. Such pumps, however, are susceptible to vapor locking, alsoreferred to as air locking or gas locking, when the fluid in the pumpintake is too high in gas phase.

Canadian patent 2,228,416 to Kisman, the content of which isincorporated herein by reference in its entirety, discloses a firstconduit that is insulated and extends within the well, from the bottomof a hydrocarbon-bearing formation to a well head. The first conduitincludes a port through which fluid enters the insulated conduit. A pumpnear the bottom of the first conduit pumps fluid from the bottom of thefirst conduit, through a second conduit that extends inside the firstconduit, to the surface. Kisman aims to separate the gas and liquidphases upon entry into the first conduit and to avoid reheating of theseparated liquid phase. The liquid phase is pumped through the secondconduit to the surface and the gas phase moves to the surface throughthe first conduit. The Kisman apparatus utilizes additional conduitsthat run coextensive with the well and the length of the first conduitand the location of the port are extremely important to promoteseparation of the liquid and gases and avoid reheating of the separatedliquids.

Improvements in apparatus for use with artificial lift are desirable.

SUMMARY

According to an aspect of an embodiment, an apparatus for use in ahydrocarbon production well includes a production well casing thatextends from a segment of the hydrocarbon production well to a wellhead.The apparatus includes a production conduit extending inside theproduction well casing, from a first end located within the hydrocarbonproduction well to a second end at the wellhead. The apparatus alsoincludes a receptacle including a receptacle bottom spaced from thefirst end of the production conduit and at least one receptacle sidewallextending around a portion of the production conduit proximal the firstend such that the receptacle extends around the first end of theproduction conduit. The receptacle includes at least one opening for thepassage of liquid into the receptacle to facilitate separation of theliquids from gases in the hydrocarbon production well. A submersiblepump is disposed in the hydrocarbon production well and includes a motordisposed outside the receptacle and coupled to a pump body disposedinside the receptacle to pump the liquid from a pump inlet in thereceptacle into the production conduit and through the productionconduit to the second end. The apparatus may be utilized in any suitablehydrocarbon production well, including, for example, a SAGD productionwell.

BRIEF DESCRIPTION OF THE DRAWINGS

Embodiments of the present invention will be described, by way ofexample, with reference to the drawings and to the followingdescription, in which:

FIG. 1 is a sectional view through a reservoir, illustrating asteam-assisted gravity drainage (“SAGD”) well pair;

FIG. 2 is a side sectional view through a hydrocarbon production wellincluding an apparatus for use in the well in accordance with anembodiment;

FIG. 3 is a side sectional view through a hydrocarbon production wellincluding an apparatus for use in the well in accordance with anotherembodiment; and

FIG. 4 is a side sectional view through a hydrocarbon production wellincluding an apparatus for use in the well in accordance with stillanother embodiment.

DETAILED DESCRIPTION

For simplicity and clarity of illustration, reference numerals may berepeated among the figures to indicate corresponding or analogouselements. Numerous details are set forth to provide an understanding ofthe examples described herein. The examples may be practiced withoutthese details. In other instances, well-known methods, procedures, andcomponents are not described in detail to avoid obscuring the examplesdescribed. The description is not to be considered as limited to thescope of the examples described herein.

The disclosure generally relates to an apparatus for use in ahydrocarbon production well that includes a production well casing thatextends from a segment of the hydrocarbon production well to a wellhead.The apparatus includes a production conduit extending inside theproduction well casing, from a first end located within the hydrocarbonproduction well to a second end at the wellhead. The apparatus alsoincludes a receptacle including a receptacle bottom spaced from thefirst end of the production conduit and at least one receptacle sidewallextending around a portion of the production conduit proximal the firstend such that the receptacle extends around the first end of theproduction conduit. The receptacle includes at least one opening for thepassage of liquid into the receptacle to facilitate separation of theliquids from gases in the hydrocarbon production well. A submersiblepump is disposed in the hydrocarbon production well and includes a motordisposed outside the receptacle and coupled to a pump body disposedinside the receptacle to pump the liquid from a pump inlet in thereceptacle into the production conduit and through the productionconduit to the second end. The apparatus may be utilized in any suitablehydrocarbon production well, including, for example, a steam-assistedgravity drainage (“SAGD”) production well.

As described above, various hydrocarbon recovery processes, such asSAGD, are known for mobilizing viscous hydrocarbons. In the SAGDprocess, a well pair, including hydrocarbon production well and a steaminjection well are utilized. One example of a well pair is illustratedin FIG. 1. The hydrocarbon production well 100 includes a generallyhorizontal segment 102 that extends near a base or bottom 104 of ahydrocarbon reservoir 106. The steam injection well 112 also includes agenerally horizontal segment 114 that is disposed generally parallel toand is spaced vertically above the horizontal segment 102 of thehydrocarbon production well.

During SAGD, steam is injected into the steam injection well 112 tomobilize the hydrocarbons and create a steam chamber in the reservoir106, around and above the generally horizontal segment 112. In additionto steam injection into the steam injection well 112, lighthydrocarbons, such as ethane, propane or butane may optionally beinjected with the steam. The volume of light hydrocarbons that areinjected is relatively small compared to the volume of steam injected.The addition of light hydrocarbons is referred to as a solvent-assistedprocess (SAP). Viscous hydrocarbons in the reservoir are heated andmobilized and the mobilized hydrocarbons drain, under the effects ofgravity. Fluids, including the mobilized hydrocarbons along with aqueouscondensate, are collected in the generally horizontal segment 102. Thefluids may also include gases, such as steam and production gases fromthe SAGD process.

Artificial lift may be utilized to facilitate the flow of the heatedhydrocarbons and aqueous condensate to the surface, for example, whenthe SAGD operation is carried out at sufficiently low pressure thatartificial lift is required to recover mobilized hydrocarbon at thesurface, or when increased rate of movement of the fluid from the wellis desirable.

An embodiment of an apparatus 200 for use with a hydrocarbon productionwell, such as the hydrocarbon production well 100 illustrated in FIG. 1,is illustrated in FIG. 2. The hydrocarbon production well 100 includesthe generally horizontal segment 102, which is a pipe, also referred toas a slotted liner, that is coupled to a production well casing 108, forexample, by a liner hanger 116. The production well casing 108 extendsfrom the generally horizontal segment 102 to the wellhead 110.

The apparatus 200 includes a production conduit 202 that extends insidethe production well casing 108, from a first end 204 located within thehydrocarbon production well 100, near the liner hanger 116, to a secondend 206 at the wellhead 110. The production conduit 202 is tubular andmay extend generally concentrically with the production well casing 108.

A receptacle 210 is disposed around the first end 204 of the productionconduit 202. The receptacle 210 includes a receptacle bottom 212 that isspaced from the first end 204 of the production conduit 202. In thisexample, the receptacle 210 includes a generally cylindrical sidewall214 that extends from the receptacle bottom 212 and around a lowerportion 216 of the production conduit 202 near the first end 204. Thegenerally cylindrical sidewall 214 may extend generally concentricallywith the production conduit 202. The receptacle 210 also includes aninwardly extending flange 218 that extends from an upper edge of thesidewall 214 to the production conduit 202. The inwardly extendingflange 218 extends inwardly to the production conduit 202 to close thetop of the receptacle 210. The sidewall 214 includes openings 219 in theinwardly extending flange 218, to allow the ingress of fluid and tofacilitate the separation of the liquids from the gases in thehydrocarbon production well 100. The openings 219 may be any suitablesize or shape to facilitate separation of liquids from the gases. Asuitable length of the sidewall 214, or distance from the bottom 212 tothe inwardly extending flange 218, is utilized to facilitate separationof liquids in the fluid. The inwardly extending flange 218 may couplethe receptacle 210 to the production conduit 202. In this example, inwhich the receptacle 210 is coupled to the production conduit, theproduction conduit may be removed or extracted from the hydrocarbonproduction well 100 for cleaning. Specialized connections may beutilized to couple sections of the production conduit 202 to facilitateextraction for cleaning of the receptacle 210.

An electric submersible pump 220 is disposed in the hydrocarbonproduction well 100 and includes a pump motor 222 that is disposedoutside of the receptacle 210, and a pump body 224 that is disposedinside the receptacle 210 and is coupled to the pump motor 222 by ashaft 230 that extends through the bottom 212 of the receptacle 210. Aseal is utilized between the receptacle bottom 212 and the shaft 230 toinhibit the flow of fluid through the bottom 212 of the receptacle 210.Thus, the fluid in the hydrocarbon production well 100 is not in fluidcommunication with the liquid in the receptacle 210 through the bottom212.

The pump body 224 includes inlets 226 disposed in the receptacle 210 anda discharge outlet 228 coupled to the first end 204 of the productionconduit 202. The discharge outlet 228 is in fluid communication with theproduction conduit 202 to pump the liquid from the receptacle 210,through the pump inlets 226, may be spaced from the bottom 212 of thereceptacle 210 or spaced from the lowest point in the receptacle 210 toprovide a space into which solids may be deposited. Fluid is pumpedthrough the pump inlets 226, into the production conduit 202, andupwardly to the second end 206 at the wellhead 110.

During the production of hydrocarbons, the fluid 234, includinghydrocarbons along with aqueous condensate, flows into the generallyhorizontal segment 102 of the hydrocarbon production well 100. The fluid234 flows into the production well casing 108 and upwardly, around thereceptacle 210. The gases in the fluid rise, as illustrated by thearrows 236, and the liquids, illustrated by the arrows 238 enter thereceptacle 210 through the openings 219. The liquids 238 are pumped,through the pump body 224, into the production conduit 202 and to thewellhead 110. The flow path of the liquids is therefore altered togenerally separate the gases and cause the gases to flow upwardly whilethe liquids enter the receptacle 210. A small amount, or small volume,of gases may still enter the receptacle 210. The gases and the liquidsseparate because the liquids, which are the heavier of the fluids,typically settle and accumulate at the bottom of the production wellcasing 108. The level of the liquids may rise above the openings 219 inthe receptacle 210 and the gases, which are the less heavy fluids, dueto buoyancy and gravity segregation. The gases therefore travel towardthe wellhead.

A SAGD production well is referred herein as one example of a productionwell in which the apparatus 200 may be utilized. Use of the apparatus200 is not limited to a SAGD production well. Instead, the apparatus maybe utilized in other production wells, including wells that utilizethermal techniques to mobilize hydrocarbons and in wells that utilizeother techniques for recovery of hydrocarbons.

The heat supplied by the motor 222 heats the temperature of the gases influids that include dissolved gases, which assists in expelling thedissolved gases from the fluids outside the receptacle 210. When theseparated liquids drop into the receptacle 210 and travel downwardly,even with some heat gain, the gas separation within the receptacle 210is significantly reduced by comparison to gas separation near the intakeof a pump without such a receptacle 210 because the fluids have alreadypassed through a more thermodynamically favourable separation condition.The heat provided by the motor 222 also results in water vapoursseparating from fluids that include water and steam and the separatedliquids fall into the receptacle 210. The temperature does notsignificantly increase when the water vapours separate because a phasechange in a single component system occurs at a constant temperature.Because the temperature does not significantly increase, little furthervaporization occurs within the receptacle 210.

Another embodiment of an apparatus 300 for use with a hydrocarbonproduction well, such as the hydrocarbon production well 100 illustratedin FIG. 1, is illustrated in FIG. 3. The hydrocarbon production well 100includes the generally horizontal segment 102, which is a pipe, alsoreferred to as a slotted liner 102 that is coupled to a production wellcasing 108, for example, by a liner hanger 116. The production wellcasing 108 extends from the generally horizontal segment 102 to thewellhead 110.

Many of the elements of the apparatus 300 are similar to those describedabove with reference to the apparatus 200 illustrated in FIG. 2 and aretherefore not described again in detail. In the present example, theliner 102 of the hydrocarbon production well 100 extends past the linerhanger 116 and partly through the production well casing 108. A sealingelement 312 is disposed in the liner 102 and forms a bottom of thereceptacle 310. The end section of the liner hanger 116 forms thegenerally cylindrical sidewall 314 of the receptacle 310. In thisembodiment, the receptacle 310 does not include an inwardly extendingflange and the top of the receptacle 310 is open. Alternatively, the topof the receptacle 310 may include an inwardly extending flange.

The electric submersible pump 320 is disposed in the hydrocarbonproduction well 100 and includes the pump motor 322 that is disposedoutside of the receptacle 310, and the pump body 324 that is disposedinside the receptacle 310 and is coupled to the pump motor 322 by ashaft 330 that extends through the sealing element 312 that acts as thebottom of the receptacle 310. The electric submersible pump 320 mayextend through the sealing element 312 by stabbing the pump 320 throughthe sealing element 312. The sealing element 312 inhibits the flow offluid through the bottom of and into the receptacle 310. Thus, the fluidin the hydrocarbon production well 100 is not in fluid communicationwith the liquid in the receptacle 310 through the sealing element 312.

As similarly described above with reference to FIG. 2, in FIG. 3 thepump body 324 includes inlets 326 disposed in the receptacle 310 and adischarge outlet 328 coupled to a first end 304 of the productionconduit 302.

The liner 102 includes perforations 340 at locations below the sealingelement 312 that act as the bottom of the receptacle 310 to facilitatethe flow of fluid from the liner 102 and into the well casing 108.

During the production of hydrocarbons, a fluid 334, includinghydrocarbons along with aqueous condensate, flows from the liner 102,through the perforations 340 into the production well casing 108 andupwardly, around the receptacle 310. The gases in the fluid rise, asillustrated by arrows 336, and the liquids, illustrated by arrows 338,enter the receptacle 310 through the open top. The liquids 338 arepumped, through the pump body 324, into the production conduit 302 andto the wellhead 110.

Yet another embodiment of an apparatus 400 for use with a hydrocarbonproduction well, such as the hydrocarbon production well 100 illustratedin FIG. 1, is illustrated in FIG. 4. Many of the elements of theapparatus 300 are similar to those described above with reference to theapparatus illustrated in FIG. 3 and are therefore not described again indetail.

In this example, a pipe 442 that is larger in diameter than theproduction conduit 402 and smaller in diameter than the well casing 108is disposed in the well casing 108, near the liner hanger 116. The pipe442 is coupled to the well casing 108 by additional packing elements 444that maintain the pipe 442 in place. A sealing element 412 is disposedin the pipe 442 and forms a bottom of the receptacle 410. The endsection of the pipe 442 forms the generally cylindrical sidewall 414 ofthe receptacle 410. In this embodiment, the receptacle 410 does notinclude an inwardly extending flange and the top of the receptacle 410is open. Alternatively, the top of the receptacle 410 may include aninwardly extending flange.

The electric submersible pump 420 is disposed in the hydrocarbonproduction well 100 and includes the pump motor 422 that is disposedoutside of the receptacle 410, and the pump body 424 that is disposedinside the receptacle 410 and is coupled to the pump motor 422 by ashaft 430 that extends through the sealing element 412 that acts as thebottom of the receptacle 410. The electric submersible pump 420 mayextend through the sealing element 412 by stabbing the pump 420 throughthe sealing element 412. The sealing element 412 inhibits the flow offluid through the bottom of and into the receptacle 410. Thus, the fluidin the hydrocarbon production well 100 is not in fluid communicationwith the liquid in the receptacle 410 through the sealing element 412.

As similarly described above with reference to FIG. 2, in FIG. 4 thepump body 424 includes inlets 426 disposed in the receptacle 410 and adischarge outlet 428 coupled to the first end 404 of the productionconduit 402.

The pipe 442 includes perforations 440 at locations between the sealingelement 412 and the additional packing elements 444 to facilitate theflow of fluid around the pipe 442 and upwardly in the well casing 108.

During the production of hydrocarbons, the fluid 434, includinghydrocarbons along with aqueous condensate, flows from the liner 102,through the perforations 440 in the pipe 442 and upwardly, around thereceptacle 410. The gases in the fluid rise, as illustrated by thearrows 436, and the liquids, illustrated by the arrows 438 enter thereceptacle 410 through the open top. The liquids 438 are pumped, throughthe pump body 424, into the production conduit 402 and to the wellhead110.

The following examples are submitted to further illustrate embodimentsof the present invention. These examples are intended to be illustrativeonly and are not intended to limit the scope of the present invention.The examples are production results utilizing a proprietary computerizedwellbore modeling simulator. The data shown is data from simulations. Ineach case, Source conditions are identified to approximate thetemperature, pressure, and composition of fluids entering a typicalproduction well in a SAGD operation. Heat losses along the wellbore weresimulated.

Example 1

This example illustrates the simulated production results from the wellcasing and from the production conduit when a receptacle, such as thereceptacle described in relation to FIG. 2, is utilized. As described,an electric submersible pump intake is disposed in the receptacle andthe motor is disposed outside the receptacle, at the bottom thereof.

The source conditions utilized were:

Water Rate=300 t/d;

Oil Rate=150 t/d; and

Methane Rate=4.63 t/d.

The following constraints were identified:

Constraint Pressure: 6.5×10⁶ Kpa; and

Constraint Rate: 454.628.

The simulated results from the production conduit were taken from alocation disposed in the receptacle, spaced from the bottom but near thebottom of the receptacle. Results from the well casing were taken from alocation disposed above the receptacle.

TABLE 1 Production Results Utilizing Receptacle properties SourceProduction Well Casing Time water bitumen methane water bitumen (days)(t) (t) (t) (t) (t) 0 0 0 0 0 0 30 0 0 0 0 0 30 0.251074 0.1255370.003804 0.017116 0.000168 30 2.951564 1.475782 0.044721 0.0171160.000168 30 15.04782 7.52391 0.227997 0.017482 0.000175 31 149.978374.98914 2.272398 0.029444 0.000203 31 300.0055 150.0027 4.5455380.109525 0.000203 32 450.0327 225.0164 6.818678 0.443841 0.000203 32600.06 300.03 9.091818 1.148552 0.000203 33 900.1144 450.0572 13.63813.51272 0.000203 34 1200.169 600.0845 18.18438 6.719242 0.000203 351500.223 750.1117 22.73066 10.61535 0.000203 36 1800.278 900.138927.27694 15.08798 0.000203 37 2100.333 1050.166 31.82322 19.560720.000203 40 3000.496 1500.248 45.46206 35.07769 0.000203 41 3300.551650.275 50.00834 40.42166 0.000203 45 4500.768 2250.384 68.1934663.96322 0.000203 50 6001.041 3000.52 90.92486 96.49311 0.000203 516301.095 3150.548 95.47114 103.0815 0.000203 55 7501.313 3750.656113.6563 130.4718 0.000203 60 9001.585 4500.792 136.3876 166.09040.000203 75 13502.4 6751.202 204.5819 281.2993 0.000203 100 21003.7610501.88 318.2388 488.6925 0.000203 150 36006.49 18003.24 545.5529932.1273 0.000204 200 51009.21 25504.61 772.8669 1395.694 0.000204 25066011.94 33005.97 1000.181 1871.863 0.000204 300 81014.66 40507.331227.495 2358.739 0.000204 350 96017.38 48008.69 1454.809 2851.6180.000204 400 111020.1 55510.05 1682.123 3351.248 0.000204 450 126022.863011.41 1909.437 3856.718 0.000204 500 141025.5 70512.77 2136.7514365.749 0.000204 properties Production Well Casing Production ConduitTime methane water bitumen methane (days) (t) (t) (t) (t) 0 0 0 0 0 30 00 0 0 30 0.00020107 5.51722288 0.008301364 7.67765E−05 30 0.0002010722.6429939 0.328802407 0.006175632 30 0.06229784 37.6143723 5.8153672220.102503106 31 1.59127522 172.920517 73.45058441 0.639277458 313.44239831 322.887756 148.4755554 1.067141294 32 5.31504583 472.590057223.4928131 1.470376372 32 7.20106697 621.920715 298.5088501 1.85897374233 11.0056677 919.622864 448.5393677 2.602339506 34 14.83686451216.47961 598.5687866 3.31843257 35 18.6885223 1512.64441 748.59753424.013718128 36 22.5567207 1808.23071 898.6257935 4.692359447 3726.4247627 2103.81689 1048.654297 5.37101841 40 38.0869789 2988.472411498.737915 7.348468781 41 41.9790764 3283.18359 1648.768066 8.00299072345 57.6059151 4459.86719 2248.878418 10.56170273 50 77.222908 5927.615722999.015869 13.67611694 51 81.1485672 6221.08301 3149.042725 14.2967634255 96.8743973 7393.91846 3749.152588 16.75188065 60 116.5734948858.57617 4499.289063 19.78393745 75 175.873993 13244.207 6749.69921928.66124725 100 275.118683 20538.1973 10500.38086 43.05823135 150474.353149 35097.5078 18001.74414 71.12123871 200 674.040283 49636.738325503.10547 98.67886353 250 874.089783 64163.3203 33004.46875 125.921051300 1074.3988 78679.2031 40505.83203 152.8976288 350 1274.8807493189.0469 48007.19141 179.7246552 400 1475.5282 107692.148 55508.55469206.3854065 450 1676.31519 122189.414 63009.91406 232.9029236 5001877.19751 136683.109 70511.28125 259.332428

As illustrated in Table 1, after 500 days, the total bitumen from thesource was 70512.77 tonnes. The total bitumen produced from theproduction conduit was 70511.28 tonnes. Very little bitumen is producedfrom the production well casing. After 500 days, the total methane gasfrom the source was 2136.75 tonnes. The total methane gas produced fromthe production well casing was 1877.20 tonnes. The total methane fromthe production conduit was 259.33 tonnes.

Thus, much of the liquids were produced through the production conduitand much of the gas was separated and produced through the productionwell casing.

Example 2

This example illustrates simulated production results from the wellcasing and from the production conduit when a receptacle is not present.Source conditions and constraints utilized were identical to thosedescribed above with reference to Example 1.

The simulated results from the production conduit were taken from thesame location relative to the well casing as in Example 1 but noreceptacle was present. Results from the well casing were taken from thesame location as in Example 1.

TABLE 2 Production Results With No Receptacle properties SourceProduction Well Casing Production Conduit Time water bitumen methanewater bitumen methane water bitumen methane (days) (t) (t) (t) (t) (t)(t) (t) (t) (t) 0.00 0 0 0 0 0 0 0 0 0 30.00 0 0 0 0 0 0 0 0 0 30.000.300054 0.150027 0.004546 0.077905 0.000767 0.000888 0.30685 1.67E−051.42E−05 30.01 3.000545 1.500273 0.045463 0.109755 0.001081 0.0010696.255856 0.504917 0.015642 30.50 150.0272 75.01362 2.27314 0.1567570.001083 0.430157 163.5936 73.83548 1.769217 31.00 300.0545 150.02724.54628 0.348671 0.001083 1.009318 313.6732 148.8664 3.467092 31.50450.0817 225.0409 6.81942 0.642781 0.001083 1.593243 463.4849 223.88535.157238 32.00 600.1089 300.0545 9.09256 1.005043 0.001083 2.180041613.2172 298.8895 6.844394 33.00 900.1635 450.0817 13.63884 1.8883960.001083 3.359571 912.5569 448.8376 10.21134 34.00 1200.218 600.108918.18512 2.981142 0.001083 4.546077 1211.738 598.709 13.57132 35.001500.272 750.1362 22.7314 4.073924 0.001083 5.732541 1510.918 748.580416.93133 36.00 1800.327 900.1635 27.27768 5.166698 0.001083 6.9190051810.099 898.4517 20.29135 37.00 2100.381 1050.191 31.82396 6.2594640.001083 8.105469 2109.279 1048.323 23.65137 40.00 3000.545 1500.27245.4628 10.21471 0.001083 11.68563 3006.325 1497.696 33.70915 41.003300.599 1650.3 50.00908 11.58594 0.001083 12.88055 3305.302 1647.46937.05997 45.00 4500.817 2250.408 68.19421 17.58536 0.001083 17.679244500.845 2246.383 50.44468 50.00 6001.089 3000.545 90.9256 25.505570.001083 23.69952 5995.055 2994.924 67.15402 51.00 6301.144 3150.57295.47189 27.05603 0.001083 24.90382 6293.965 3144.668 70.49548 55.007501.362 3750.681 113.657 32.86282 0.852873 29.73366 7489.076 3743.37783.84832 60.00 9001.634 4500.817 136.3884 40.39681 3.010169 35.796698981.937 4491.253 100.516 75.00 13502.45 6751.226 204.5826 64.3298710.47331 54.04676 13458.94 6734.112 150.4607 100.00 21003.81 10501.91318.2396 106.4586 24.16001 84.56349 20918.25 10471.06 233.6012 150.0036006.54 18003.27 545.5536 194.9442 53.68817 145.7794 35832.58 17942.85399.6823 200.00 51009.26 25504.63 772.8676 287.0654 85.02808 207.143850743.23 25412.86 565.6212 250.00 66011.98 33005.99 1000.182 381.5346117.5289 268.6006 65651.52 32881.71 731.4697 300.00 81014.71 40507.361227.496 477.5292 150.7812 330.1155 80558.27 40349.81 897.2678 350.0096017.43 48008.71 1454.81 573.8802 184.2078 391.6404 95464.66 47817.731063.057 400.00 111020.2 55510.08 1682.124 670.231 217.6342 453.1653110371 55285.66 1228.845 450.00 126022.9 63011.44 1909.438 766.5814251.0619 514.6907 125277.4 62753.59 1394.635 500.00 141025.6 70512.82136.751 862.9318 284.4959 576.2169 140183.8 70221.52 1560.423

As illustrated in Table 2, after 500 days, the total bitumen from thesource was 70512.8 tonnes. The total bitumen produced from theproduction conduit was 70221.52 tonnes. The total bitumen produced fromthe production well casing was 284.50 tonnes. After 500 days, the totalmethane gas from the source was 2136.75 tonnes. The total methane gasproduced from the production well casing was 576.22 tonnes. The totalmethane from the production conduit was 1560.42 tonnes.

Thus, a much greater percentage of gas is produced through theproduction conduit than in Example 1. Gas separation is greatly improvedand less gas enters the electric submersible pump in Example 1. Similaradvantages are expected utilizing other embodiments of the receptacles,such as those shown in FIG. 3 and FIG. 4.

Advantageously, the motor 222 of the electric submersible pump 220 isdisposed outside of the receptacle 210. Heat generated from the motor222 raises the temperature of the fluid, which may include gases andliquid outside of the receptacle 210. Also, electric submersible pumpsheat up during use in a hydrocarbon production well, which may reducethe life of the pump. By locating the motor 222 outside of thereceptacle 210, the motor 222 is cooled by a large volume of fluid fromthe hydrocarbon production well. Thus, a large volume of fluid may beutilized to exchange heat with the pump and thereby cool the motor. Lessheat is generated inside the receptacle. Optionally, all or part of thereceptacle 210 may be insulated to reduce heat transfer through thereceptacle 210, to the liquid in the receptacle 210. In one example, thebottom 212 of the receptacle 210 may be insulated to reduce heating ofthe liquid in the receptacle 210 by, for example, the pump motor 222.The insulation, however, is not required and the receptacle 210 may beadvantageously utilized without insulation. Furthermore, only oneproduction conduit is utilized and may be located generallyconcentrically within the production casing. The use of a packer is notnecessary.

The described embodiments are to be considered in all respects only asillustrative and not restrictive. The scope of the claims should not belimited by the preferred embodiments set forth in the examples, butshould be given the broadest interpretation consistent with thedescription as a whole. All changes that come with meaning and range ofequivalency of the claims are to be embraced within their scope.

What is claimed is:
 1. An apparatus for use in a hydrocarbon productionwell that includes a production well casing that extends from a segmentof the hydrocarbon production well to a wellhead, the apparatuscomprising: a production conduit extending inside the production wellcasing, from a first end located within the hydrocarbon production wellto a second end at the wellhead; a receptacle including a receptaclebottom spaced from the first end of the production conduit and at leastone receptacle sidewall extending around a portion of the productionconduit proximal the first end such that the receptacle extends aroundthe first end of the production conduit, the receptacle including atleast one opening therein for the passage of liquid into the receptacleto facilitate separation of the liquids from gases in the hydrocarbonproduction well; and a submersible pump disposed in the hydrocarbonproduction well and comprising a motor disposed outside the receptacleand coupled to a pump body disposed inside the receptacle to pump theliquid from a pump inlet in the receptacle into the production conduitand through the production conduit to the second end.
 2. The apparatusaccording to claim 1, wherein the pump body is coupled to the motor by acoupling that extends through the receptacle bottom.
 3. The apparatusaccording to claim 2, wherein fluid in the hydrocarbon production wellis not in fluid communication with the liquid in the receptacle throughthe receptacle bottom.
 4. The apparatus according to claim 1, whereinthe receptacle comprises an inwardly extending flange that extends froman upper edge of the receptacle sidewall.
 5. The apparatus according toclaim 4, wherein the inwardly extending flange extends inwardly to theproduction conduit.
 6. The apparatus according to claim 5, wherein theinwardly extending flange includes at least one opening to facilitatethe flow of liquid into the receptacle.
 7. The apparatus according toclaim 1, wherein the receptacle sidewall is generally cylindrical. 8.The apparatus according to claim 1, wherein the receptacle sidewall isgenerally concentric with the production conduit
 9. The apparatusaccording to claim 1, wherein the receptacle sidewall is generallyconcentric with the production well casing.
 10. The apparatus accordingto claim 1, wherein a top of the receptacle is open to facilitate theflow of liquid into the receptacle.
 11. The apparatus according to claim1, wherein the receptacle sidewall is comprised of a top portion of thesegment of the hydrocarbon production well and the bottom is comprisedof a sealing element disposed in the segment.
 12. The apparatusaccording to claim 11, wherein the segment of the hydrocarbon productionwell includes openings between the sealing element and a bottom of theproduction well casing to facilitate the flow of fluid from the segment,around the receptacle.
 13. The apparatus according to claim 1, whereinthe receptacle sidewall is comprised of a portion of a pipe disposed inthe production well casing and the bottom is comprised of a sealingelement disposed in the pipe.
 14. The apparatus according to claim 13,wherein the pipe is coupled to the production well casing by at leastone packing element.
 15. The apparatus according to claim 14, whereinthe pipe includes openings disposed between the sealing element and theat least one packing element to facilitate the flow fluid from thesegment, around the receptacle.
 16. The apparatus according to claim 1,wherein the receptacle is insulated to reduce heat transfer through thereceptacle, to the liquid in the receptacle.
 17. The apparatus accordingto claim 1, wherein the receptacle bottom is insulated to reduce heattransfer through the receptacle bottom, to the liquid in the receptacle.